Transmission Planning

Attachment K Public Input

Meeting Minutes

FERC 890 Q2

June 12, 2014

Attendees:Jamie Austin

Lori Adams

JD Podlesnik

Larry Frick

Brian Fritz

Dennis Yegorov

Patience Kerchinsky

Peter Jones

Mark Adams

Dave Hagen

Dan Yokota - BPA

Gayle MacKenzie – Scribe

  • Welcome attendees and guest- Jamie Austin
  • Explain the planning process – Jamie Austin
  • Finalized methodology/planning criteria/process used
  • Coordinate with other processes on reliability
  • TPL transmission planning studies
  • Five year area studies
  • Generator interconnection studies
  • PacifiCorp to review with stakeholders the status of 5-year studies as they become available
  • Stakeholders can submit study requests through OASIS process
  • No study requests submitted in Q1
  • Next time study request to be submitted is Q5
  • Eight Quarter Process for PacifiCorp
  • Year 1 – 2014
  • Q1 Jan-Mar ~ Data collection for economic studies
  • Q2 Apr-Jun ~ Reference case development
  • Q3 Jul-Sep ~ Economic studies to identify congestion
  • Q4 Oct-Dec ~ Draft reporting
  • Year 2 – 2015
  • Q5 Jan – Mar ~ Draft report on system adequacy
  • Data collection for re-study
  • Q6 Apr – Jun ~ Draft re-study report review
  • Q7 Jul – Sep ~ Final report and review
  • Q8 Oct – Dec ~ Final transmission plan approval
  • Generator Interconnection Requests – Brian Fritz
  • Generator interconnection requests
  • Nearly 600 applications in 2004
  • 106 actual projects completed
  • Generator interconnection requests by size and year
  • Interconnect requests by type and year
  • 2003 – 100% wind; no solar
  • 2013 & 2014 – 80% solar requests; 5% wind
  • The majority in Southern Utah follow FERC process
  • Local Area Studies Update – PACW – Larry Frick
  • Yreka
  • 85% complete
  • Progress delayed by compliance-related activities
  • Crescent City & Grants Pass
  • 65% complete
  • Study progressing
  • 41 months average study length - PACW
  • Normal is 36 months
  • Local Area Studies Update – PacifiCorp East – Mark Adams
  • Studies
  • Ogden – Q2 2014 complete
  • Utah (Southwest) – Q2 2014 complete
  • Goshen – Q3 2014 – complete
  • Nebo – Q2 2014 complete
  • Utah Valley – Q3 2014 complete
  • Also scheduled in 2014
  • Honeyville/Malad
  • Powder River
  • Pavant
  • Smithfield
  • Montpelier
  • 48 months average study length
  • Goal is 36 months
  • 4 years ago the normal was 24 months
  • Caused by decrease in planning engineers
  • Yreka Area Study – Dennis Yegorov
  • Study area covers
  • Yreka
  • Shasta Valley
  • Montague
  • Rural areas
  • Lower Klamath River
  • Hornbrook
  • Happy Camp
  • Scott Valley
  • Fort Jones
  • Etna
  • Weed
  • Southern Part of the study area
  • Mount Shasta
  • Sacramento Canyon
  • McCloud
  • Dunsmuir
  • Rural areas south
  • Yreka has 8 ties to other systems
  • Medford (2)
  • Klamath Falls (3)
  • Cave Junction (1)
  • Pacific Gas & Electric’s system in Cottonwood area (2)
  • Study area is served by 35 substation
  • 9 transmission substations/switching stations
  • 26 distribution substations
  • Local generation within study area
  • Six hydroelectric plants
  • Customer-owned steam turbine generator in Weed
  • Base System Loads (coincidental)
  • Summer 2014 – 94 MW
  • Growth rate 0.4%
  • Winter 2014-2015 – 110 MW
  • Growth rate 0.4%
  • Projected system loads (coincidental)
  • Summer 2018 96 MW
  • Winter 2019-2019 113 MW
  • Distribution Substation Capacity
  • Summer 162.8 MVA
  • Winter 204.0 MVA
  • Distribution Substation Utilization Factor
  • Summer 2014 62.5%
  • Winter 2014-2015 56.0%
  • Transmission System Losses
  • 6-7% of area load during peak load periods
  • 6 Planned System Improvements
  • Four near-term planning horizon (years 1 through 5)
  • Weed 115-69kV LTC transformer
  • In service winter 2015 - 2016
  • Yreka 115-69kV LTC transformer
  • In service 2016
  • 2nd Yreka – Greenhorn 69kV line
  • In service 2017
  • Lassen distribution substation
  • In service 2017 (depending on load growth)
  • Two long-range planning horizon (beyond 5 years)
  • 69kV line 2 conversion to 115kV
  • Phase 1 – Weed Junction – Lassen Segment
  • Project timing depends on future load development in Mount Shasta area
  • Phase 2 – Copco – Weed Junction segment
  • Timing driven by future load development in Yreka, Weed and Mount Shasta area
  • Contact information – Link to PacifiCorp OASIS
  • For Attachment K related comments/questions, address your requests to
  • Next meeting late September 2014
  • Meeting adjourned